Frac head apparatus

ABSTRACT

A frac head apparatus has a body with an internal bore extending therethrough, a first flow bore formed through the body so as to have an inner end opening to the internal bore of the body and an outer end opening to an outer side of the body, and a second flow bore formed through the body so as to have an inner end opening to the internal bore of the body and an outer end opening at an outer side of the body. The inner end of the first and second flow bores are positioned at different levels within the body. Each of the first and second flow bores has a longitudinal axis offset from and not intersecting a longitudinal axis of the internal bore of the body such that a fluid flow through the flow bores is directed toward a wall of the internal bore offset from an opposite side of the wall of the internal bore from the inner ends of the flow bores.

CROSS-REFERENCE TO RELATED APPLICATIONS

Not applicable.

STATEMENT REGARDING FEDERALLY SPONSORED RESEARCH OR DEVELOPMENT

Not applicable.

NAMES OF THE PARTIES TO A JOINT RESEARCH AGREEMENT Not applicable.

INCORPORATION-BY-REFERENCE OF MATERIALS SUBMITTED ON A COMPACT DISC

Not applicable.

BACKGROUND OF THE INVENTION

1. Field of the Invention

The present invention relates to frac head apparatus. More particular,the present invention relates to frac head apparatus whereby a cyclonicflow of fluid is induced into the internal bore of the frac head. Moreparticular, the present invention relates to frac heads having aplurality of flow bores cooperative at the internal bore of the frachead.

2. Description of Related Art Including Information Disclosed Under 37CFR 1.97 and 37 CFR 1.98.

Well fracturing operations are well known in the oil and gas drillingindustries for increasing the flow capacity of a well. During a typicalwell fracturing operation, large amounts of abrasive and/or acidicfluids (i.e. slurries of sand, water, and various chemicals) are pumpeddown the well by high-pressure pumps. The high-pressure fluids (andsometimes gels) are intended to fracture the formation, therebyimproving the permeability and flow capacity of the hydrocarbons. A frachead is typically connected to the wellhead (or above the wellhead).Multiple fluid lines connect the frac head to correspondinghigh-pressure pumps (typically pump trucks). The frac head acts as amanifold to collect and redirect fluid from the multiple fluid linesdown through the well head into the wellbore.

Because of the abrasive and corrosive nature of the fracturing fluids,the interior bore of the frac head can be subject to extreme erosion.Such erosion is costly in that it can severely limit the useful servicelife of the frac head. The frac head wall typically needs to besufficiently thick to support pressures of up to about 15,000 p.s.i.,fluid velocities of 200 ft/min or more, and fluid flow rates of 100gallons per second or more. Eroded frac heads can sometimes be repaired,but are often simply scrapped. Due to the high fluid pressures, frachead erosion also potentially poses a serious safety concern. Frac headruptures are known in the process of fracturing.

Numerous approaches have been taken in the past to address frac headerosion. For example, frac heads have been fabricated from thick-walledsteel and/or with high-strength construction materials. The innersurface of the frac head has also been lined with various erosionresistant materials. Unfortunately, these approaches have met withminimal success, most likely due, in part, to the extremely highpressures and fluid flow rates.

The frac head is a common upper wellhead stationary inlet and outletmulti-bore flow manifold that is used when injecting fluids or materialswithin the internal bore of a traditional petrochemical oil or gas well,as well as being additionally applied toward the internal self-propelledpetrochemical fluid. A traditional frac head manifold is commonly usedto provide service toward all fluidous flow transfer operations ormotion-induced material flow transfers within the internal bore and/orflow path of a wellhead Christmas tree assembly. The frac head is awellhead assembly designed for typical positioning above the upper Csection of a fully assembled wellhead assembly in order for the frachead to be positioned generally above all of the critical wellheadsafety control devices and safety regulatory systems, such as thosedevices which control, monitor, adjust and regulate all open flow linebores and closed flow line bores. These items are commonly known as thelower hydraulic-actuated gate valves, the lower manually-actuated gatevalves, and any pilot-operated automatic actuated gate valve assemblies.The wellhead assembly configuration can include various configurationsof wellhead casing heads, casing hangers, casing spools, tubing heads,tubing hangers, tubing spools, height riser spools, adapter spools,crossover adapters, test adapters, and the integral main bore section.

The most common types of damaging effects generated by near continuousabrasive flow cavitation toward a common frac head are abrasive internalwall material washout within the entire length of the internal bore oralong the affixed flow line components. These can continuously degradeduring service applications so as to thereby produce a gradual productfailure and deterioration. This can ultimately result in various productfailure conditions. These failure conditions can include decreases inthe upstream accessory flow line wall thickness, high pressure and highvolume abrasive deformation of the internal wall thickness, anddeformation of the internal wall surface integrity. This can develop acondition, as a result of the initial internal cavitation and internalflow washout, wherein the actual washout generated by the internalcavitation activities of the flow process begin to develop a significantcompounding effect toward the wall thickness washout and materialdestruction.

The most common damaging effects generated by near continuousnon-abrasive flow cavitation include non-abrasive internal componentdamage with the entire upstream sectional lengths of the internal boreof the flow line or the affixed flow line components. These cancontinuously degrade during service application so as to eventuallyproduce product failure and deterioration. This can ultimately result invarious degrees of product failure conditions which include damage tointernal upstream flow line elastomer seals, seal kits, seal gaskets,0-rings and other elastomer or wearable flow line components.

When traditional frac heads are utilized as a means of wellhead flowinjection or flow outlet, the frac head is configured in a mannerconsistent with the fluid flow or material flow mass volumes which areinternally directed in a standard uniform fashion in which the internalfluid flow or material flow is firstly injectably directed toward thecenter axis point of the internal bore in which there is an opposing ornear directly center axis point of the internal borehorizontally-aligned bore section which creates a situation in whicheach of the independent injection flow bores are directly facing oneanother on an equal horizontal axis alignment plane from the centerpoint of the internal axis of the internal bore. As such, all of thepressurized injected fluids or flow materials create a bullhead-typedirect flow mass flow volume compression interference with one anotherat the point of injection into the internal bore of the frac head. Thiscan generate a higher rate of injection mass flow cavitation and alessening of the inlet mass flow pulsation dampening effects. As aresult, a less consistently smooth fluid flow occurs. This is due to thefact that the traditional frac head is configured in a manner in whichall of the flow bores are manufactured in a simple equal horizontalalignment around the internal diameter circumference of the frac headand at the outer diameter circumference of the frac head. This producesa flow process resulting from the colliding effect of the injected fluidflow or material flow. An aggressively forceful and highly pressurizeddirect alignment collision with these fluid flows occurs at the initialpoint of confluence at or near the vertical center axis of the internalbore section of the frac head. This collision can be deleterious to theoptimum operating conditions of the frac head.

Standard frac heads are all manufactured with the individual flow boresbeing aligned generally in a near radially equal horizontal center axisaround the outer diameter of the frac head as well as a near radiallyequal horizontal center axis around the inside diameter of the internalbore of the frac head. The flow bores are thus positioned in nearlyequally opposing relationship in the flow bore. An example of this iswhen traditional frac heads are equipped with an industry-standard fourside outlets or a more expensive version equipped with six side outlets.These side outlets are known as the inlet and outlet flow bores. Eachflow bore will continuously generate a tremendous amount of undesirableconfluence and flow turbulence. This results in a significant internalwashout effect to the internal bore of the frac head as well as washoutof the wellhead components which are positioned and affixed below andabove the frac head. Premature product failure of the traditional frachead is generated by these various forms of destructive fluid flow.Traditional frac heads are configured to provide the means for inletinjection and outlet exhaustion of fluid flow or material flow volumesto create a near-centrally located point of confluence of all of theavailable flow bores. This can create damaging effects toward the entireinternal bore when the traditional frac head is utilized for the purposeof inlet injection of fluid flow. Traditional frac heads are designedwith the individual flow bores in an angular configuration in which theindependent flow bores are all generally configured to match the sameangle of flow bore alignment. These angles of flow bore alignment aretypically machined within a traditional frac head at three principaldegrees of angle from the vertical center point of the internal bore.These angles can be configured at 90°, 45° and 30° off the center pointaxis of the internal bore the frac head. These various degrees of angledo not eliminate the destructive high-pressure injection of fluid and donot eliminate the washout or damaging abrasive cavitation.

In the past, various patents have issued with respect to such frac headsin an effort to minimize the destructive effect caused by fluidinjection. For example, U.S. Pat. No. 7,478,673, issued on Jan. 20, 2009to M. D. Boyd, describes a frac head that includes a mixing chamberlocated in an internal bored downstream of an intercept between the sideports in the internal bore and upstream of a tapered vortex portion ofthe bore. The tapered vortex reduces the diameter of the bore from afirst diameter to a second diameter. The length of the mixing chamber(along the longitudinal axis of the frac head) is greater than the firstdiameter. The ratio of the first diameter to the second diameter isgreater than 1.5.

U.S. Pat. No. 7,828,153, issued on Nov. 9, 2010 to McGuire et al.,describes a multipart frac head with replaceable components which permitthe frac head to be refurbished in the field. A bottom leg of themultipart frac head is replaceable. The inlet ports of the frac head arealso replaceable.

U.S. Pat. No. 8,016,031, issued on Sep. 13, 2011 to B. McGuire, shows anerosion resistant frac head having a conversion chamber. The frac headalso includes an expansion chamber and a mixing chamber so as to provideimproved resistance to erosion caused by abrasive frac fluids pumpedthrough the frac head. A bottom leg of the erosion resistant frac headmaybe replaced in the field.

U.S. Patent Application Publication No. 2013/0075079, published a Mar.28, 2013 to D. L. Artherholt, describes a frac head having a sacrificialwash ring. The sacrificial wash ring is located above a mixing chamberso as to protect the frac head body from erosion caused by abrasive fracfluids pumped through the head.

It is an object of the present invention to provide a frac headapparatus that improves overall cycle durability.

It is another object of the present invention to provide a frac headapparatus that allows for improved long-lasting performance of theupstream components.

It is another object of the present invention to provide a frac headapparatus that provides a less restrictive flow process.

It is another object of the present invention to provide a frac headapparatus that has a smoother inlet injection flow.

It is a further object of the present invention to provide a frac headapparatus that reduces damaging effects caused by abrasive andnon-abrasive flow processes, cavitation, and back pressure to upstreamcomponents.

It is another object of the present invention to provide a frac headapparatus that generates an injection-based cyclonic flow effect.

It is another object of the present invention to provide a frac headapparatus that reduces vibratory cavitation washout.

It is another object of the present invention to provide a frac headapparatus that reduces premature product failure.

It is another object of the present invention to provide a frac headapparatus that is more cost effective.

It is still a further object of the present invention to provide a frachead apparatus that allows for the option of alternating or eliminatingthe use of more expensive quinteplex-type injection pumps.

It is still a further object of the present invention to provide a frachead apparatus that makes available the use of cheaper triplex injectionpumps.

It is still a further object the present invention to provide a frachead apparatus that serves to maintain bore wall thickness and reducematerial washout.

These and other objects and advantages of the present invention willbecome apparent from a reading of the attached specification andappended claims.

BRIEF SUMMARY OF THE INVENTION

The present invention is a frac head apparatus that includes a bodyhaving an internal bore extending therethrough with an inlet at an upperend thereof and an outlet at a lower end thereof. A first flow bore isformed through the body so as to have an inner end opening to theinternal bore of the body and an outer end opening at an outer side ofthe body. The first flow bore angles through the body such that theinner end is at a level lower than the outer end. A second flow bore isformed through the body so as to have an inner end and an outer end. Theinner end of the second flow bore is positioned opposite the inner endof the first flow bore. The second flow bore angles through the bodysuch that the inner end of the second flow bore is at a level lower thanthe outer end of the second flow bore. In one embodiment, the inner endof the first flow bore is at a level different than the inner end of thesecond flow bore.

The first flow bore has a longitudinal axis offset from and notintersecting a longitudinal axis of the internal bore of the body suchthat a fluid flow through the first flow bore is directed toward a wallof the internal bore offset from an opposite side of the wall of theinternal bore from the inner end of the first flow bore. The second flowbore extends angularly through the body at an angle relative to thelongitudinal axis of the internal bore. The angle of the second flowbore is similar to the angle at which the first flow bore extendsrelative to the longitudinal axis of the internal bore. The second flowbore has a longitudinal axis offset from and not intersecting thelongitudinal axis of the internal bore of the body such that a fluidflow through the second flow bore is directed to the wall of theinternal bore offset from an opposite side of the wall of the internalbore from the inner end of the second flow bore. The longitudinal axisof the first flow bore is in parallel planar relationship to alongitudinal axis of the second flow bore. The inner end of the secondflow bore is positioned at a level above the inner end of the first flowbore.

A third flow bore is formed through the body so as to have an inner endand an outer end. The inner end of the third flow bore opens to theinternal bore of the body of location circumferentially between theinner ends of the first and second flow bores. The third flow boreangles through the body such that the inner end of the third flow boreis at a level lower than a level of the outer end of the third flowbore. A fourth flow bore is formed to the body so as to have an innerend and an outer end. The inner end of the fourth flow bore opens to theinternal bore of the body in a location circumferentially between theinner ends of the first and second flow bores and located generallyopposite to the location of the inner end of the third flow bore. Thefourth flow bore extends through the body such that the inner end of thethird flow bore is at a level lower than a level of the outer end of thethird flow bore. The third flow bore angles through the body at an anglerelative to the longitudinal axis of the internal bore of the body. Thefourth flow bore also angles through the body at an angle relative tothe longitudinal axis of the internal bore of the body. The angle of thethird flow bore is similar to the angle of the fourth flow bore. Theinner end of the third flow bore is diametrically opposite the inner endof the fourth flow bore.

In the present invention, the inner ends of the first, second, third andfourth flow bores are at different levels relative to the longitudinalaxis of the internal bore of the body. The third flow bore has alongitudinal axis offset from and not intersecting the longitudinal axisof the internal bore of the body such that a fluid flow through thethird flow bore is directed toward the wall of the internal bore offsetfrom an opposite side of the wall of the internal bore from the innerend of the third flow bore. Similarly, the fourth flow bore haslongitudinal axis offset and not intersecting the longitudinal axis ofthe internal bore of the body such that a fluid flow through the fourthflow bore is directed toward the wall of the internal bore offset froman opposite side of the wall of the internal bore from the inner end ofthe fourth flow bore. In an embodiment of the present invention, thelongitudinal axis of the third flow bore is in parallel planarrelationship to the longitudinal axis of the fourth flow bore.

This foregoing Section is intended to describe, with particularity, thepreferred embodiments of the present invention. It is understood thatmodifications to these preferred embodiments can be made within thescope of the present claims without departing from the true spirit ofthe present invention. As such, the Section should not be construed aslimiting, in any way, the broad scope of the present invention. Thepresent invention should only be limited by the following claims andtheir legal equivalents.

BRIEF DESCRIPTION OF THE SEVERAL VIEWS OF THE DRAWINGS

FIG. 1 is side elevational view showing the frac head apparatus of thepresent invention.

FIG. 2 is a cross-sectional view showing the frac head apparatus inaccordance with the teachings of the present invention.

FIG. 3 is a cross-sectional view in a horizontal plane of the frac headapparatus of the present invention.

FIG. 4 is a perspective view of an alternative version of the frac headapparatus of FIG. 1 showing six fluid connections.

FIG. 5 is a perspective view of an alternative embodiment of the frachead apparatus of the present invention.

FIG. 6 is a cross-sectional view of the alternative embodiment of thefrac head apparatus of the present invention.

DETAILED DESCRIPTION OF THE INVENTION

Referring to FIG. 1, there is shown the frac head apparatus 10 inaccordance with the present invention. The frac head apparatus 10includes a body 12 having a flange 14 located at an upper end thereofand a flange 16 located at a bottom end thereof. Flow bores 18 and 20are illustrated as formed within the body 12. Each of the flow bores 18and 20 includes respective fluid connections 22 and 24. Fluidconnections 22 and 24 are suitable for connection to a fluid inlet oroutlet pipe. Another accessory component 26 is formed on the body 12 andincludes an accessory line 28 applied in bolted connection at theconnector 30 thereof. The body 12 includes an inlet 32 located at theupper end thereof and an outlet 34 located at the bottom end thereof.Each of the inlet 32 and the outlet 34 will communicate with an internalbore (not shown) extending through the body 12.

The flange connections 14 and 16 are basic API-6A-type flanged endconnections that are suitable for connection to a variety of wellheadassembly components. These components are generally located at a verytop of the wellhead Christmas tree assembly, such as a general flangedend connection toward the top of the wellhead's tubing head unit. Theseflange connections 14 and 16 can also be connected to any type ofadapter or crossover-type adapter for application toward the top side ofan upper outlet bore section of a variety of optional API-6A-typeconnections for use when the wellbore is serviceably connected forspecialized operations, such as wireline injection services,snubbing-type wellbore operations and general fracture injectionpractices toward the wellbore. The top side upper inlet bore section isgenerally where the blind tree cap or bottom hole test adapter tree capwill be connectably affixed toward the frac head flow enhancement flowsystem in order to provide a blind plug-type or test plug-type servicetoward the upper main inlet bore section. The body 12 can be generallyequipped with any number of six flow bore chambers that can beconnectably engaged toward secondary attachable API-6A-type connectionsin order to perform the inlet injection and outlet exhaustion practicesof wellbore-related fluids and chemicals. These integrally positionedside-mounted inlet and outlet flow bore chambers are generally comprisedof API-6A-type flanged end side studded outlets for jointable connectiontoward all companion type API-6A unions and adapter.

FIG. 2 is a cross-sectional view of the frac head apparatus 10 of thepresent invention as taken across a vertical plane. In FIG. 2, it can beseen that the body 12 has an internal bore 36 having an inlet 32 at theupper end thereof and an outlet 34 at a lower end thereof. The firstflow bore 18 is formed through the body 12 so as to have an inner end 38opening to the internal bore 36 of the body 12 and an outer end 40opening at an outer side of the body 12. The first flow bore 18 anglesthrough the body 12 such that the inner end 38 is at a level lower thana level of the outer end 40. A second flow bore 42 (illustrated in FIG.1 as connected to the accessory component 26) has an inner end 44 and anouter end 46. The second flow bore 42 extends through the body 12 suchthat the inner end 44 opens to the internal bore 36 of the body 12. Theinner end 44 is at a level lower than the outer end 46 of the secondflow bore 42. The accessory component 26 is illustrated as bolted to theflange 27 associated with the second flow bore 42.

FIG. 3 also illustrates that there is a third flow bore 48 and a fourthflow bore 50 that will be positioned so as to open to the internal bore36 of the body 12. The third flow bore 48 and the fourth flow bore 50will be positioned between the first flow bore 18 and the second flowbore 42. The inner ends 38 and 44 are at generally positioneddiametrically opposite to one another within the internal bore 36.Similarly, the third flow bore 48 and the fourth flow bore 50 arepositioned generally diametrically opposite to each other within theinternal bore 36 of the body 12.

FIG. 2 illustrates that there is a tubing string 52 that is positionedso as to extend through the internal bore 36. The tubing string can havea specialty tool 54 mounted thereto. The tubing string 52 is illustratedso as to extend so as to have a lower end extending outwardly of thelower end of the body 12.

In FIG. 2, the first flow bore 18 extends angularly through the body 12such that the inner end 38 is at a level lower than the outer end 40.Similarly, the second flow bore 42 extends through the body 12 such thatthe inner end 44 is at a level lower than the outer end 46. As such,fluids can be directed downwardly from the outer side of the body 12.The angle of the first flow bore 18 is similar to the angle of thesecond flow bore 42.

In FIG. 2, it can be seen that in broken lines that there is a zone ofconfluence 55 located within the internal bore 36. As fluid is directedthrough the flow bores 18, 42, 48 and 50, the flows will converge in acyclonic manner within this zone of confluence 55. As such, the uniqueeffects created by the present invention are achieved within this zoneof confluence 55.

FIG. 3 illustrates the configuration of the flow bores 18, 42, 48 and50. The flow bores 18, 42, 48 and 50 are illustrated across a horizontalplane and illustrated in the manner in which these flow bores will angletoward the internal bore 36 of the body 12.

In particular, the first flow bore 18 has a longitudinal axis offsetfrom and not intersecting the longitudinal axis 56 of the internal bore36. As such, a fluid flowing through the first flow bore 18 is directedtoward a wall 58 of the internal bore 36 that is offset from theopposite side of the wall 58 from the internal bore 36. Similarly, thesecond flow bore 42 has a longitudinal axis offset and not intersectingthe longitudinal axis 56 of the internal bore 36 of the body 12 suchthat fluid passing through the second fluid flow bore 42 is directed tothe wall 58 of the internal bore 36 offset from the opposite side of thewall 58 from the inner end 44 of the flow bore 42. The third flow bore48 and fourth flow bore 50 will have similar configurations. As can beseen in FIG. 3, the longitudinal axis of the first flow bore 18 will bein parallel planar relationship to the longitudinal axis of the secondflow bore 42. The longitudinal axis of the third flow bore 48 will be inparallel planar relationship to the longitudinal axis of the fourth flowbore 50.

FIG. 4 shows a modification 60 of the frac head apparatus 10 of FIG. 1.In FIG. 4, it can be seen that there are a total of six (6) flow boresconnected to the body 62 and extending therethrough. Each of these flowbores 64, 66, 68, 70 and 72 will have a configuration similar to theflow bores illustrated in FIGS. 2 and 3. As such, fluid passing throughthese flow bores will be directed in a cyclonic manner into the internalcavity 74 extending through the body 62.

FIG. 5 shows an alternative embodiment of the frac head apparatus 80 ofthe present invention. In FIG. 5, it can be seen that there is a firstflow bore 82, a second flow bore 84, a third flow bore 86 and a fourthflow bore 88. Each of the flow bores 82, 84, 86 and 88 are arranged atdifferent levels along the side 90 of the body 92. The body 92 willgenerally have the same configuration as the body 12 (as shown in FIG.1).

FIG. 6 illustrates that the first flow bore 82 extends at an anglethrough the body 92 of the frac head apparatus 80. Similarly, the secondflow bore 84 extends at an angle through the body 92 of the frac headapparatus 80. The inner end 94 of the first flow bore 82 is located at alevel lower than the inner end 96 of the second flow bore 84. Similarly,the inner end 98 of the third flow bore 86 is located at a lower levelthan the level of the inner end 100 of the fourth flow bore 88. In FIG.6, it can be seen that these inner ends 94, 96, 98 and 100 are eachlocated at different levels within the internal bore 102 of the body 92.This arrangement of flow bores will achieve a unique cyclonic flow path(illustrated by broken line 104) within the internal bore 102. Thevarious fluid flows will encounter each other within a zone ofconfluence (illustrated by broken line area 106). As such, this is adifferent technique for achieving a similar cyclonic form of flowdelivery of fluids through the frac head apparatus 80.

The frac head apparatus of the present invention provides an advancedflow process within the frac head assembly. This generates an advancedmethod of high-pressure flow dynamics in order to produce an optimalfluid flow or material flow through the use of the injected fluid flow.The arrangement of the present invention is capable of providing a truemethod of automatic vortical flow inlet injection through a variety andany number of flow bores. As a result, a generally cyclonic flow isachieved with vortical flow characteristics developed at or near thecenter point axis of the internal bore of the frac head apparatus.

The present invention provides a substantial service improvement inoverall lifecycle durability in the long-lasting performance of all thecomponents connected to the upstream flow side of the frac head. This isthe result of the fact that the apparatus of the present inventionprovides for a less restrictive flow process throughout the full flowinlet injection pathway within the internal bore. This allows a smootherinlet injection flow to develop which significantly reduces knowndamaging effects such as abrasive and non-abrasive cavitation as well asflow line back pressure toward the upstream accessory equipment that canbe affixed to or connected to the frac head apparatus. These upstreamcomponents can include high-pressure triplex or quinteplex fluidinjection pumps, segmental high-pressure flow line components, flexiblehose flowlines, flow diverters, and directional flow control manifoldsystems.

The cyclonic injection effect is achieved by manipulating the standardflow bores of a traditional frac head so as to provide a slightly offsetangular degree of inlet injection so as to generate a downwardlyspiraling fluid flow at the plenum of the internal bore. This cycloniceffect generated by the flow system of the present invention reducesvibratory cavitation washout and premature product failure situationstoward all internal upstream flow components or controls connectedthereto. These components can include the upstream pump's internal valveseats, drive plungers, drive pistons, body housings, crankshafts, flowmanifold end sections, high-pressure flow line connections, connectableconduit unions and flow line hoses.

The reduction in flow process cavitation and subsequent pulsationdampening creates a working environment in which the injection ofhigh-pressure material flow can be accomplished by a high-pressure inletinjection pump and related inlet injection pump systems jointablyconnected toward a high-pressure inlet injection pump, electronic drivesystems, diesel-power drive systems, natural gas-power drive systems,solar-powered drive systems, secondary-power drive systems and operationcontrol modules. One example of such a type is a standardquinteplex-type injection pump which operates by means of fiveindividual direct drive pistons or drive plungers. The operation of thepresent invention allows the user to utilize, instead of such aquinteplex pump, a more cost-effective triplex injection pump. Thetriplex injection pump operates by means of only three direct drivepistons or drive plungers in order to provide the necessary inletpressure required to artificially inject high-pressure oil and gaswells. The frac head apparatus of the present invention offers theservice operator an option of alternating and/or eliminating the use ofthe higher cost quinteplex-type injection pump in favor of a downsizedtriplex-type injection pump. This significantly lowers the pressurepumping operating costs and all associated downtime maintenance andrelated operating costs associated with the more expensive piece ofequipment.

The present invention significantly reduces those common destructiveelements of flow processes that can prematurely destroy the frac head'sservice application. The present invention develops and promotes a lessrestrictive fluid flow and/or material flow cavitation effect. As such,the present invention minimizes any abrasive wash-out effects so as toprovide for a longer-lasting product service. This additional flowprocess configuration is developed by means of altering the angulardegree of inlet injection reception of each individual flow bore bymeans of offsetting the angular bore configuration of the flow boreswhich is generally angularly offset from a near perpendicular alignmentof the radial internal diameter circumference of the internal boretoward a modified development of the flow bores to any degree of offsetof the flow bores at a near equal angular proximity toward the nextsequential flow bore degree of angle which is not equallyperpendicularly aligned with the internal diameter of the internal boreof the frac head system. This achieves a desired decrease in visiblyevidenced erosive and/or abrasive effects. The present invention alsoeliminates those problems associated with non-abrasive washout. Theinitial flow injection flow bores are configured at an offset of anydegree of angular offset from the radial axis internal diameter of theinternal bore in order to first provide a means of automaticallygenerating a cyclonic turbine effect toward any fluids or materialsinjected within the flow bores and to secondarily pre-align inletinjected fluid flow and/or material flow elements in a manner which isof a lessening effect with respect to cavitation and abrasive and/ornon-abrasive washout. The present invention provides a fluid flow whichenhances smooth flow dynamics within the flow bores and within theinternal bore of the system.

The frac head apparatus of present invention reduces the forcefulimpacts of fluid flow and/or material flow elements by creating a simpledirectional uniform angular offset of the injection flow bores in orderto develop a downward forced injection cyclonic fluid flow toward thefluid elements that are applied through the frac head. The angular inletinjection offset of the flow path of the flow bores reduces destructiveinternal flow cavitation, increases pulsation dampening and reducesdestructive abrasive and non-abrasive washout. When the flow bores areconfigured in a spiral wound configuration, the angular offset of theflow bores is more defined since they are each at a further distancefrom one another within the spiral wound configuration.

The frac head apparatus of the present invention can be applied toward aservice application for which material flow is injected, such as adownhole liquefied cement injection head. Such a cement injection headis commonly utilized to provide artificially pressurized inlet injectionand artificially pressurized inlet injection back-filling of liquefiedcement, liquefied cement fluidous formulas or compounds, and fluidouscement gravel pack materials into the vacant cavity developed betweenthe installed downhole casing string and the maximum internal diameterof the originally-drilled wellbore in order to establish the finalinstallation and permanent setting of the downhole casing stringassembly.

The present invention reduces common wear, abrasive wear, non-abrasivewear and specialized downhole tooling damage. Such downhole tooling caninclude instrumentation, electronics, sensors, data transfer devices,recorders, and hardware and software components that are permanentlyinstalled or temporarally positioned within the internal wellbore casingstring or tubing string. The present invention avoids such damage due toan increase in downhole fluid flow and/or material flow pulsationdampening so as to significantly reduce the effects of the fluid flow,the cavitation, and the non-abrasive and abrasive washout. Thisreduction of the generally damaging effects applies toward allconnectably engaged and jointably engaged wellhead components that aresurface-based and are made up either above the frac head apparatus ormounted below the frac head apparatus. The present invention isapplicable to subsea-type wellhead assemblies and wellbore completionoperations.

The frac head apparatus of the present invention provides a serviceapplication by way of an angular offset of the flow bores in relation toa directionally uniform angular offset of the inlet injection bores inorder to develop a downward forced injection spiraling cyclonic fluidflow. This downward forced spiraling cyclonic inlet injection isenhanced by providing the near same angular inlet injection offset ofeach individual internal bore of the flow bore path angle in which eachindividual internal bore of the flow bore is integrally machined withinthe main body housing in order to actively effect all accessorycomponent flowlines or secondary conduit units. As such, thesecomponents can establish a common straight line extension toward theflow bore in an orientation at the same linear angle of the flow pathdirection. This creates a uniform flow path relation to the internalbores so as to develop a straight extended length of injection flow oroutlet exhaustion flow.

All secondary straight sections that are externally affixed to the frachead apparatus provide an internal straight flow path which is nearlyequally aligned in the same linear flow path as the internal bores ofthe flow bores to provide a greater internal flow path length section.This helps to develop an optimal performance toward the spiral woundcyclonic flow path.

The foregoing disclosure and description of the invention isillustrative and explanatory thereof. Various changes in the details ofthe illustrated construction can be made within the scope of theappended claims without departing from the true spirit of the invention.The present invention should only be limited by the following claims andtheir legal equivalents.

I claim:
 1. A frac head apparatus comprising: a body having an internal bore extending therethrough, said internal bore having an inlet at an upper end thereof and an outlet at a lower end thereof; a first flow bore formed through said body so as to have an inner end opening to said internal bore of said body and an outer end opening at an outer side of said body, said first flow bore angling through said body such that said inner end is at a level lower than said outer end; and a second flow bore formed through said body so as to have an inner end and an outer end, said inner end of said second flow bore being positioned opposite said inner end of said first flow bore, said second flow bore angling through said body such that said inner end of said second flow bore is at a level lower than said outer end of said second flow bore, said inner end of said first flow bore being at a level different than a level of said inner end of said second flow bore.
 2. The frac head apparatus of claim 1, said first flow bore having a longitudinal axis offset and not intersecting a longitudinal axis of said internal bore of said body such that a flow through said first flow bore is directed toward a wall of said inner bore offset from an opposite side of said wall of said internal bore.
 3. The frac head apparatus of claim 1, said second flow bore angling through said body at an angle relative to the longitudinal axis of said internal bore, said angle of said second flow bore being similar to an angle at which said first flow bore extends relative to the longitudinal axis of said internal bore.
 4. The frac head apparatus of claim 2, said second flow bore having a longitudinal axis offset from and not intersecting the longitudinal axis of said internal bore of said body such that a fluid flow through said second flow bore is directed toward said wall of said internal bore offset from an opposite side of said wall of said internal bore.
 5. The frac head apparatus of claim 4, said longitudinal axis of said first flow bore being in parallel planar relationship to a longitudinal axis of said second flow bore.
 6. The frac head apparatus of claim 1, said inner end of said second flow bore positioned at a level above said inner end of said first flow bore.
 7. The frac head apparatus of claim 1, further comprising: a third flow bore formed through said body so as to have an inner end and an outer end, said inner end of said third flow bore opening to said internal bore of said body in a location circumferentially between said inner ends of said first and second flow bores, said third flow bore angling through said body such that said inner end of said third flow bore is at a level lower than a level of said outer end of said third flow bore.
 8. The frac head apparatus of claim 7, further comprising: a fourth flow bore formed through said body so as to have an inner end and an outer end, said inner end of said fourth flow bore opening to said internal bore of said body in a location circumferentially between inner ends of said first and second flow bores and generally opposite to said inner end of said third flow bore, said fourth flow bore angling through said body such that said inner end of said fourth flow bore is at a level lower than a level of said outer end of said fourth flow bore.
 9. The frac head apparatus of claim 8, said third flow bore angling through said body at an angle relative to the longitudinal axis of said internal bore of said body, said fourth flow bore angling through said body at an angle relative to the longitudinal axis of said internal bore of said body, said angle of said third flow bore being similar to said angle of said fourth flow bore.
 10. The frac head apparatus of claim 8, said inner end of said third flow bore being diametrically opposite said inner end of said fourth flow bore.
 11. The frac head at apparatus of claim 8, said inner ends of said first flow bore, said second flow bore, said third flow bore and said fourth flow bore being at different levels relative to the longitudinal axis of said internal bore of said body.
 12. The frac head apparatus of claim 9, said third flow bore having a longitudinal axis offset and not intersecting the longitudinal axis of said internal bore of said body such that a fluid flow through said third flow bore is directed toward the wall of said internal bore offset from an opposite side of said wall of said internal bore from said inner end of said third flow bore.
 13. The frac head apparatus of claim 12, said fourth flow bore having a longitudinal axis offset from and not intersecting the longitudinal axis of said internal bore of said body such that a fluid flow through said fourth flow bore is directed to said wall of said internal bore offset from an opposite side of said wall of said internal bore from said inner end of said fourth flow bore.
 14. The frac head apparatus of claim 13, said longitudinal axis of said third flow bore being in parallel planar relationship to the longitudinal axis of said fourth flow bore.
 15. A frac head apparatus comprising: a body having an internal bore extending therethrough, said internal bore having an inlet at an upper end thereof and an outlet at a lower end thereof; a first flow bore formed through said body so as to have an inner end opening to said internal bore of said body and an outer end opening at an outer side of said body, said first flow bore angling through said body such that said inner end is at a level lower than said outer end, said first flow bore having a longitudinal axis offset and not intersecting a longitudinal axis of said internal bore of said body such that a fluid flow through said first flow bore is directed toward a wall of said internal bore offset from an opposite side of said internal bore from said inner end of said first flow bore; and a second flow bore formed through said body so as to have an inner end and an outer end, said inner end of said second flow bore being positioned opposite said inner end of said first flow bore, said second flow bore angling through said body such that said inner end of said second flow bore is at a level lower than said outer end of said second flow bore, said second flow bore having a longitudinal axis offset from and not intersecting the longitudinal axis of said internal bore of said body such that a fluid flow through said second flow bore is directed toward said wall of said internal bore offset from an opposite side of said wall of said internal bore from said inner end of said second flow bore.
 16. The frac head apparatus of claim 15, said second flow bore angling through said body at an angle relative to the longitudinal axis of said internal bore, said angle of said second flow bore being similar to an angle at which said first flow bore extends relative to the longitudinal axis of said internal bore.
 17. The frac head apparatus of claim 16, further comprising: a third flow bore formed through said body so as to have an inner end and outer end, said inner end of said third flow bore opening to said internal bore of said body in a location circumferentially between said inner ends of said first and second flow bores, said third flow bore angling through said body such that said inner end of said third flow bore is at a level lower than a level of said outer end of said third flow bore; and a fourth flow bore formed through said body so as to have an inner end and an outer end, said inner end of said fourth flow bore opening to said internal bore of said body in a location circumferentially between said inner ends of said first and second flow bores and generally opposite to said inner end of said third flow bore, said fourth flow bore angling through said body such that said inner end of said fourth flow bore is at a level lower than a level of said outer end of said fourth flow bore.
 18. The frac head apparatus of claim 15, said inner end of said second flow bore positioned at a level above said inner end of said first flow bore.
 19. A frac head apparatus comprising: a body having an internal bore extending therethrough, said internal bore having an inlet at an upper end thereof and an outlet at a lower end thereof; a first flow bore formed through said body so as to have an inner end opening to said internal bore of said body and an outer end opening at an outer side of said body, said first flow bore angling through said body such that said inner end is at a level lower than said outer end; a second flow bore formed to said body so as to have an inner end and an outer end, said inner end of said second flow bore being positioned opposite said inner end of said first flow bore, said second flow bore angling through said body such that said inner end of said second flow bore is at a level below said outer end of said second flow bore; a third flow bore formed through said body so as to have an inner end and an outer end, said inner end of said third flow bore opening to said internal bore of said body in a location circumferentially between said inner ends of said first and second flow bores, said third flow bore angling through said body such that said inner end of said third flow bore is at a level lower the level of said outer end of said third flow bore; and a fourth flow bore formed through said body so as to have an inner end and an outer end, said inner end of said fourth flow bore opening to said internal bore of said body in a location circumferentially between said inner ends of said first and second flow bores and generally opposite said inner end of said third flow bore, said fourth flow bore angling through said body such that said inner end of said fourth flow bore is at a level lower than a level of said outer end of said fourth flow bore.
 20. The frac head apparatus of claim 19, said inner ends of said first flow bore and second flow bore and said third flow bore and said fourth flow bore being positioned at different levels within said body. 